Fullbore Wireline Pumpthrough Tool

ABSTRACT

A pumpdown sub for use with a downhole tool during pumpdown operations includes a valve with a valve member that selectively opens and closes. When the valve is open, fluid can flow axially past the pumpdown sub, thus the downhole tool can be moved up and down in the wellbore without flow resistance from the pumpdown sub. When the valve is closed, the valve member blocks substantially the entire cross sectional area of the wellbore, so that when pumpdown fluid is added to the wellbore, the fluid does not flow around the valve, but instead all of the pumped fluid exerts a pumpdown force onto the valve and tool. The sub is adjustable for use within

BACKGROUND OF THE INVENTION

1. Field of Invention

The present disclosure relates in general to a device for use in wireline pumpdown applications.

2. Description of Prior Art

Some hydrocarbon producing wellbores have portions that are deviated or generally horizontal. Downhole tools, such as for perforating, imaging, workover, and the like, are usually inserted into the wellbores either prior to production from the wellbore, or at a time after production has initiated. Urging the downhole tools through the deviated/horizontal portions can be done with an attached tractor that pushes or pulls the tool through the non-vertical wellbore portion. Other techniques employed for urging the downhole tool deeper into deviated or horizontal portions include applying pressurized fluid to “pump-down” the tool. Attachments are sometimes provided with the downhole tools for assisting and reducing fluid utilization in pump down efforts. Pump down attachments typically project radially outward from the downhole tool adjusting to varying tubular inner diameter to occupy most of the annular space between the tool and wall of the wellbore.

SUMMARY OF THE INVENTION

Disclosed herein is an example of a system and method of pumping down in a wellbore. In an example, a pumpdown sub includes a body having an end that selectively couples to a downhole tool which is inserted into a downhole tubular, a valve member that is selectively changeable from an open configuration in which the valve member lies in a plane substantially parallel with an axis of the downhole tubular, to a closed configuration in which the valve member lies in a plane substantially perpendicular with the axis of the downhole tubular and in which the outer diameter of the valve member is in close contact with the inner diameter of the downhole tubular. Also included is an actuator coupled with the valve member, so that when the actuator is activated, the valve member is moved between the open and the closed configurations. The valve member can be planar and can have an outer diameter that is substantially the same as an inner diameter of the downhole tubular. In this example, the actuator is made up of a motor and an arm with an end connected to the motor and a distal end coupled with a planar surface of the valve member and which is offset from a middle of the valve member. In an example, the body has upper and lower portions, and wherein semi-elliptically shaped basket elements connect the upper and lower portions. Further included in this example is a hinge pin that extends lengthwise through the valve member and has opposing ends anchored in the basket elements. Stop elements may be included on the basket elements for stopping movement of the valve member. The arm can be pivotingly coupled to the valve member. In one embodiment, the basket elements extend radially outward from the body and contact the inner diameter of the downhole tubular. The valve member may include upper and lower body portions that are hingedly affixed to one another along a path that intersects a middle area of the downhole tubular. In this example, the upper and lower body portions have a semi-circular outer periphery. The upper and lower body portions can have a middle portion that resembles a half pipe, and have lateral portions that extend radially outward from sides of the middle portion towards the inner diameter of the downhole tubular. A worm gear may optionally be coupled with the actuator, and that selectively engages pinion gears that couple to the upper and lower members, so that when the actuator rotates the worm gear, the valve member changes between the open and closed configurations.

Another example of a pumpdown sub includes a body that attaches to a downhole tool in a wellbore, an open space in the body, a hinge member projecting into the space, and a valve member in the space that hingedly mounts on the hinge member and that is moveable from an open configuration where the valve member is oriented substantially parallel with an axis of the body, to a closed configuration where the valve member is oriented substantially perpendicular with the axis of the body. In an alternate example, elliptically shaped basket members are further included that circumscribe the space and have ends secured to the body. The valve member can be planar, and can have an outer diameter that is substantially the same as an inner diameter of the downhole tubular and wherein the actuator comprises a motor with an arm that couples with a planar surface of the valve member at a location offset from a middle of the valve member. Optionally, the valve member includes upper and lower body portions that are hingedly affixed to one another along a path that intersects a middle area of the downhole tubular, wherein the upper and lower body portions have a semi-circular outer periphery. In this alternate embodiment, the upper and lower body portions can have a middle portion that resembles a half pipe, and lateral portions that extend radially outward from sides of the middle portion towards the inner diameter of the downhole tubular.

In a method of pumpdown operations, provided is a downhole tool having a pumpdown valve that is changeable from an open configuration and substantially parallel with an axis of the wellbore, to a closed configuration and substantially perpendicular with the axis of the wellbore. The tool is deployed in the wellbore, and dropped in the wellbore when the pumpdown valve is in the open configuration, and fluid is pumped into the wellbore to urge the tool deeper into the wellbore when the pumpdown valve is in the closed configuration. Alternatively, in a later operational stage, the valve can be returned to the open position to allow downhole tool retrieval to surface. The example method can further include pulling the tool upward within the wellbore when the pumpdown valve is in the open configuration.

BRIEF DESCRIPTION OF DRAWINGS

Some of the features and benefits of the present invention having been stated, others will become apparent as the description proceeds when taken in conjunction with the accompanying drawings, in which:

FIGS. 1A and 1B are side sectional views of an example of a pump down operation of a downhole string and in accordance with the present invention.

FIG. 2A is a side sectional view of an example of a pump down sub in an open configuration for use with the downhole string of FIGS. 1A and 1B and in accordance with the present invention.

FIG. 2B is a side sectional view of an example of a pump down sub in a closed configuration for use with the downhole string of FIGS. 1A and 1B and in accordance with the present invention.

FIG. 2C is a side sectional view of an alternate example of a pump down sub in a closed configuration for use with the downhole string of FIGS. 1A and 1B and in accordance with the present invention.

FIG. 2D is a side sectional view of an example of the pump down sub of FIG. 2C in an open configuration for use with the downhole string of FIGS. 1A and 1B and in accordance with the present invention.

FIG. 3A is a perspective and partial sectional view of an alternate example of a pump down sub in an open configuration for use with the downhole string of FIGS. 1A and 1B and in accordance with the present invention.

FIG. 3B is a perspective and partial sectional view of an alternate example of a pump down sub in a closed configuration for use with the downhole string of FIGS. 1A and 1B and in accordance with the present invention,

FIG. 4 is a side sectional view of an example of the pump down sub of FIG. 3B and in accordance with the present invention.

FIG. 5A is a side sectional view of an alternate example of a pump down sub, which is adjustable, and in accordance with the present invention.

FIGS. 5B-5D are axial sectional views of the pump down sub of FIG. 5A in accordance with the present invention.

FIG. 5E is a plan view of an example of a shutter blade for use with the pump down sub of FIG. 5A and in accordance with the present invention.

FIGS. 6A and 6B are side sectional views of another alternate example of a pump down sub and shown respectively in a closed and open configuration for use with the downhole string of FIGS. 1A and 1B and in accordance with the present invention.

While the invention will be described in connection with the preferred embodiments, it will be understood that it is not intended to limit the invention to that embodiment. On the contrary, it is intended to cover all alternatives, modifications, and equivalents, as may be included within the spirit and scope of the invention as defined by the appended claims.

DETAILED DESCRIPTION OF INVENTION

The method and system of the present disclosure will now be described more fully hereinafter with reference to the accompanying drawings in which embodiments are shown. The method and system of the present disclosure may be in many different forms and should not be construed as limited to the illustrated embodiments set forth herein; rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey its scope to those skilled in the art. Like numbers refer to like elements throughout. In an embodiment, usage of the term “about” includes ±5% of the cited magnitude. In an embodiment, usage of the term “substantially” includes ±5% of the cited magnitude.

It is to be further understood that the scope of the present disclosure is not limited to the exact details of construction, operation, exact materials, or embodiments shown and described, as modifications and equivalents will be apparent to one skilled in the art. In the drawings and specification, there have been disclosed illustrative embodiments and, although specific terms are employed, they are used in a generic and descriptive sense only and not for the purpose of limitation.

FIG. 1A is a side sectional view of an example of a downhole string 10 inserted within a wellbore 12. In the example of FIG. 1A, the downhole string 10 is depicted as a perforating string, but can be any tool disposed within the wellbore 12, such as an imaging tool, workover tool, or any other tool used for downhole operations. The wellbore 12 is shown intersecting a subterranean formation 14 that may be a source of hydrocarbons. Wellbore 12 is lined with casing 15 for providing a barrier between the wellbore 12 and formation 14. The downhole string 10 is shown deployed on wireline 16, however, other deployment means may be utilized, such as cable, slick line, tubing, or any other known or later developed downhole tool conveyance means. A surface truck 18 is shown connected to the upper end of wireline 16 and may be used for raising and lowering the wireline 16, and thus string 10, and for providing signals via the wireline 16 to the string 10. The signals can be for controlling the string 10, as well as for monitoring conditions within the wellbore 12.

Wireline 16 is shown threaded through a wellhead assembly 20 which is mounted on surface and over wellbore 12. As indicated above, downhole string 10 is depicted as a perforating string and is shown including a series of perforating guns 22 that are equipped with perforating shaped charges 24. When the shaped charges 24 are detonated, metal jets 26 are created that form perforations 28 within formation 14. A connector sub 30 is shown connecting adjacent perforating guns 22. The downhole string 10 is shown further equipped with a pumpdown sub 32 on its lower end. Optionally, pumpdown sub 32 (or multiple pumpdown subs 32) can be integral anywhere within the string 10, or above an uppermost end of string 10. A valve member 34 is schematically illustrated within pumpdown sub 32, and in an open configuration. In the open configuration, valve member 34 is substantially parallel with an axis A_(X) of wellbore 12; thus any fluid being pumped into wellbore will flow freely past the pumpdown sub 32 and not be blocked by valve member 34.

Referring now to FIG. 1B, the valve member 34 is shown having been actuated from its open configuration of FIG. 1A and into a closed configuration. In the closed configuration, valve member 34 extends generally perpendicular to axis A_(X) of wellbore 12. In the open configuration of FIG. 1A the pumpdown sub 32 does not substantially contribute to drag forces when the string 10 is being raised and lowered within wellbore 12. In contrast, while in the closed configuration of FIG. 1B valve member 34 blocks any fluid flow across the pumpdown sub 32. The closed configuration, therefore enhances pumpdown operations when fluid from pump system 36 is pressurized in pump 38, and flows into wellbore 12 via line 40. Unlike any prior art systems that allow pumpdown fluid to flow in an annular space between the walls of wellbore 12 and whatever downhole tool is being pumped down, the pumpdown sub 32 disclosed herein blocks substantially all flow around the associated downhole string 10. The pumpdown sub 32 of FIG. 1B therefore provides for a responsive pumpdown operation such that all fluid being pumped into the wellbore 12, when the valve member 34 is in the closed configuration, can directly contribute to a pumpdown force for urging the string 10 deeper into the wellbore 12.

Referring now to FIG. 2A, one example embodiment of the pumpdown sub 32 is shown in a cross-sectional view. In this example, valve member 34 is a generally disk-like member and has a diameter substantially the same as an inner diameter casing 15. Further, a hinge pin 42 is shown projecting laterally through valve member 34, and upon which valve member 34 can rotate. An actuator arm 44 is shown coupled to a lower planar surface of valve member 34 via an anchor post 46 with an end mounted onto that planar surface. Anchor post 46 is a substantially solid member having a free end opposite the end mounted to valve member 34. In the illustrated embodiment, arm 44 pivotingly couples to anchor post 46 proximate its free end, and offset from the axis A_(X) of the pumpdown sub 32. The end of actuator arm 44 distal from anchor post 46 couples with an actuator motor 48 shown mounted within an annular upper body portion 50. Further in the example of FIG. 2A, the end of upper body portion 50 distal from valve member 34 is coupled with a lower end of perforating gun 22. As pointed out above, instead of perforating gun 22, the tool within the tool string 10 (FIG. 1) can be any tool used for downhole operations and is not limited to a perforating gun. A series of basket elements 52 are shown connected to the end of upper body portion 50 proximate to valve member 34. In an example, basket elements 52 are rib-like and semi-elliptically-shaped. On the lower or opposite end of the basket elements 52, a lower body portion 54, which is also annular, is coupled to the ends of basket elements 52 distal from upper body portion 50. The basket elements 52 have mid-portions that project radially outward from valve member 34 and are shown in contact with the inner diameter of casing 15, whereas their opposing ends are disposed radially inward for connecting with the upper and lower body portions 50, 54. In the example of FIG. 2A, the pumpdown sub 32 is depicted in the open configuration.

FIG. 2B, actuator motor 48 has been actuated so that it draws the arm 44 inward and rotates valve member 34 as illustrated by arrow A, and moves valve member 34 into the closed position. Moreover, valve member 34 is moved away from its parallel position to axis A_(X) of FIG. 2A, and into an orientation where valve member 34 is substantially perpendicular to axis A_(X). When perpendicular to axis A_(X), the valve member 34 blocks substantially all flow of fluid F adjacent valve member 34 that is pumped downward within casing 15. Accordingly, by blocking the flow of fluid F, a force is transferred to the downhole string 10 (FIG. 1) for urging the downhole string 10 deeper within wellbore 12 (FIG. 1A). As shown, flow of fluid F is blocked on upward facing planar surface of valve member 34. Further in the example of FIG. 2B, a series of stops 56 are shown strategically mounted on the radially inward facing surfaces of basket elements 52, stops 56 thereby provide a mechanical interference with the rotational motion of valve member 34 so that valve member 34 does not rotate past the perpendicular orientation. By virtue of the stops 56, valve member 34 can remain in the closed configuration until motor actuator 48 is activated to push valve member 34 into its open position of FIG. 2A.

FIGS. 2C and 2D illustrate in side sectional view and example of an alternate embodiment of pumpdown sub 32A. Here valve member 34A is made up of multiple elements that pivot about pin 42A for opening/closing the pumpdown sub 32A and selectively allowing/blocking flow through sub 32A. In FIG. 2C the sub 32A is in the closed position with the elements of the valve member 34B oriented transverse to the direction of flow of fluid F. By actuating motor 48 and drawing arms 44A towards motor 48, as shown in FIG. 2D, the elements of the valve member 34B pivot about pins 42A and so that they are substantially parallel with a path of the flow of fluid F thereby allowing fluid to flow through the sub 32A and without resistance.

FIG. 3A and FIG. 3B illustrate in perspective view an alternate example of pumpdown sub 32B, wherein valve member 34B is made up of an upper valve member 58 and lower valve member 60 (FIG. 3B). A hinge 62, which is oriented in a direction generally perpendicular to axis A_(X) and extends into the middle portion of casing 15, hingedly couples together the upper and lower valve members 58, 60. Thus, when in the open configuration of FIG. 3A, the upper and lower valve members 58, 60 are in a clam-like configuration, and then when in the closed configuration of FIG. 3B, portions of the upper and lower valve members 58, 60 are generally co-planar, and extend radially outward away from one another towards the inner diameter of casing 15. As shown in FIG. 3A, each of the upper and lower valve members 58, 60 include lateral portions 64, which have a forward facing edge that extends generally perpendicular to axis A. Rearward facing surfaces of the lateral portions 64 are curved, and extend axially away from the forward edge with distance proximate to the outer diameter of lower body portion 54. Lateral section 64 are joined by a middle portion 66 which resembles a half pipe configuration; middle portion 66 has lateral sides that are generally parallel with axis A_(X), and has a configuration that generally follows the surface of the lower body portion 54 between its lateral edges. Middle portion 66 has a forward edge 68 which regresses in a rearward direction proximate its middle, so that when the upper and lower valve members 58, 60 move into the closed configuration of FIG. 3B, the middle portion 66 does not interfere with the housing of the valve member 34B. Further illustrated in FIGS. 3A and 3B, is a motor 70 for providing opening and closing forces to the upper and lower valve members 58, 60. A controller 72, which may include electronics, printed circuit boards, and the like, is for transmitting and receiving signals to and from motor 70 for operation of motor 70. A worm gear 74 extends axially rearward from motor 70 and on a side opposite from controller 72. In an example, worm gear 74 mechanically actuates the upper and lower valve members 58, 60.

A side sectional view of the pumpdown sub 32B is illustrated in FIG. 4 and depicts the worm gear 74 having threads 76 along its outer surface. Pinion gears 80 are further shown within the housing 81 of the sub 32B and are for coupling together the upper and lower valve members 58, 60 to worm gear 74 and motor 70. In the example of FIG. 4, valve members 58, 60 are shown in the closed position and for blocking flow of fluid F through casing 15. Optionally, brackets 82 are provided for coupling together the pinion gears 80 with upper and lower valve members 58, 60. As the upper and lower valve members 58, 60 occupy a generally circular space when in the closed position; each of these resembles a generally semicircular shape when viewed from above.

Shown in side sectional view in FIG. 5A, and in axial sectional view in FIGS. 5B-5D, are alternate examples of pumpdown sub 32C. FIGS. 5B-5D are axial views taken respectively along lines 5B-5B, 5C-5C, and 5D-5D of FIG. 5A. Here the valve member 34C includes a series of shutter blades 84 that are generally triangularly shaped planar members, and that fan radially outward from axis A_(X) of pumpdown sub 32C. The outer radial edges of each of the blades 84 are attached to a one of the bow spring arms 86, when opened, the blades 84 slide against adjacent blades 84. FIG. 5E illustrates a plan view of an example of a single shutter blade 84. Arms 86 are elliptically shaped and rib like members, and in an example are similar to the basket elements 52 (FIG. 4). Upward ends of the bow spring arms 86 pivotingly mount to an arm linkage 86 which has an annular portion that threadingly mounts onto worm gear 74C shown attached to motor 70C. An end of arm linkage 86 is shown in example locations (L₁, L₂, L₃), within housing 81B, where it is selectively urged by rotating worm gear 74C with actuation of motor 70C. The ends of bow spring arms 86 distal from arm linkage 88 pivotingly mount to lower body portion 54. In an alternative a centralizer (not shown) may be included on the lower body 54 for centralizing the sub 32C, where the centralizer can include rollers on pivoting scissor type linkage members and that contact the inner surface of the tubular. A motor and screw gear assembly can be used to deploy the rollers into contact with the tubular.

Strategically actuating motor 70C to rotate worm gear 74C and selectively moving arm linkage 88 to various locations, such as locations L₁, L₂, L₃, urges the middle portion of bow spring arms 86 radially outward, where their outward extension is limited by the diameter of the particular tubular in which the sub 32C is inserted. As shown, example casing 15B has a larger diameter than example casing 15A. Casings 15A and 15B are not concentric, but shown in the same figure to illustrate how the sub 32C can be placed within and operated in conjunction with different sized downhole tubulars.

Referring now to FIG. 5D, shown in axial view is a portion of sub 34C of FIG. 5A which includes an annular gear 92 which circumscribes an annular strength member 94 which has a feed through 96 (such as a wireline for transmitting signals). An annular shaft 98 is disposed concentrically between the member 94 and gear 92.

FIGS. 6A and 6B show another alternate embodiment of a pump down sub 32D respectively in a closed and in an open configuration. Referring to FIG. 6A, the valve member 34D includes upper and lower valve members 58D, 60D that each have a hollow hemi-spherically shaped body, whose respective surfaces facing the basket elements 52 are generally planar along a path parallel with axis A_(X) and generally curved along a path transverse to axis A_(X). The rearward ends of members 58D, 60D are pivotable about hinge 62D from the open position of FIG. 6A to the closed position of FIG. 6B. In the open position, the axial lengths of members 58D, 60D are generally parallel with axis A_(X), and when in the closed position, the axial lengths of members 58D, 60D are generally transverse with axis A_(X). Bands 100, 102 are shown on the edges of members 58D, 60D proximate axis A_(X) when members 58D, 60D are in the closed position. In an example, the bands 100, 102 have a thickness greater than a thickness of the bodies of the members 58D, 60D. The forward end 104 of band 100 extends axially rearward of band 102 and radially below band 102 to form a cowling like arrangement that diverts the flow of fluid F past the interface between bands 100, 102. Diverting the flow of fluid F with the forward end 104 reduces resultant forces from causing the sub 32D to move from the closed configuration of FIG. 6A to the open configuration of FIG. 6B. The forward end 104 can also reduce stresses and vibrations in the members 58D, 60D by diverting flow around members 58D, 60D that might otherwise flow between them. In the example of FIG. 6B, the flow of fluid F has urged members 58D, 60D apart and caused them to pivot about hinge 62D and into the open configuration shown. In the open configuration, a resulting force from the flow of fluid F can urge the string attached to sub 32D in the direction of the flow of fluid F.

The present invention described herein, therefore, is well adapted to carry out the objects and attain the ends and advantages mentioned, as well as others inherent therein. While a presently preferred embodiment of the invention has been given for purposes of disclosure, numerous changes exist in the details of procedures for accomplishing the desired results. For example, the subs disclosed herein can be oriented axially opposite to that of the figures so that when fluid produced from the formation 14 (FIG. 1A) flows into the wellbore 12, the string 10 is urged upward and out of the wellbore 12. Alternatively, multiple subs can be included in the string 10 that have different orientations, so that fluid impinging a first oriented sub produces a resultant force that urges the string 10 deeper into the wellbore 12 during pumpdown operations. In this example, a second oriented sub, oriented substantially opposite the first oriented sub, can generate a force from produced fluid that urges the string 10 from the wellbore 12. Yet further optionally, e-line, slick line, wired tubing, coiled tubing, and combinations thereof may be used in place of wireline. These and other similar modifications will readily suggest themselves to those skilled in the art, and are intended to be encompassed within the spirit of the present invention disclosed herein and the scope of the appended claims. 

What is claimed is:
 1. A pumpdown sub comprising: a body having an end that selectively couples to a downhole tool which is inserted into a downhole tubular; a valve member that is selectively changeable from an open configuration in which the valve member lies in a plane substantially parallel with an axis of the downhole tubular, to a closed configuration in which the valve member lies in a plane substantially perpendicular with the axis of the downhole tubular and in which the outer diameter of the valve member is in close contact with the inner diameter of the downhole tubular; and an actuator coupled with the valve member, so that when the actuator is activated, the valve member is moved between the open and the closed configurations.
 2. The pumpdown sub of claim 1, wherein the valve member is planar and has an outer diameter that is substantially the same as an inner diameter of the downhole tubular.
 3. The pumpdown sub of claim 2, wherein the actuator comprises a motor and an arm with an end connected to the motor and a distal end coupled with a planar surface of the valve member and which is offset from a middle of the valve member.
 4. The pumpdown sub of claim 2, wherein the body comprises upper and lower portions, wherein semi-elliptically shaped basket elements connect the upper and lower portions,
 5. The pumpdown sub of claim 4, further comprising a hinge pin that extends lengthwise through the valve member and has opposing ends anchored in the basket elements.
 6. The pumpdown sub of claim 4, further comprising stop elements on the basket elements for stopping movement of the valve member.
 7. The pumpdown sub of claim 2, wherein the arm is pivotingly coupled to the valve member.
 8. The pumpdown sub of claim 4, wherein the basket elements extend radially outward from the body and contact the inner diameter of the downhole tubular.
 9. The pumpdown sub of claim 1, wherein the valve member comprises upper and lower body portions that are hingedly affixed to one another along a path that intersects a middle area of the downhole tubular.
 10. The pumpdown sub of claim 9 wherein the upper and lower body portions have a semi-circular outer periphery.
 11. The pumpdown sub of claim 10, wherein the upper and lower body portions have a middle portion that resembles a half pipe, and have lateral portions that extend radially outward from sides of the middle portion towards the inner diameter of the downhole tubular.
 12. The pumpdown sub of claim 9, further comprising a worm gear coupled with the actuator that selectively engages pinion gears that couple to the upper and lower members, so that when the actuator rotates the worm gear, the valve member changes between the open and closed configurations.
 13. A pumpdown sub comprising: a body that attaches to a downhole tool in a wellbore; an open space in the body; a hinge member projecting into the space; and a valve member in the space that hingedly mounts on the hinge member and that is moveable from an open configuration where the valve member is oriented substantially parallel with an axis of the body, to a closed configuration where the valve member is oriented substantially perpendicular with the axis of the body.
 14. The pumpdown sub of claim 13, further comprising elliptically shaped basket members that circumscribe the space and have ends secured to the body.
 15. The pumpdown sub of claim 13, wherein the valve member is planar and has an outer diameter that is substantially the same as an inner diameter of the downhole tubular and wherein the actuator comprises a motor with an arm that couples with a planar surface of the valve member at a location offset from a middle of the valve member.
 16. The pumpdown sub of claim 13, wherein the valve member comprises upper and lower body portions that are hingedly affixed to one another along a path that intersects a middle area of the downhole tubular, wherein the upper and lower body portions have a semi-circular outer periphery, and wherein the upper and lower body portions comprise a middle portion that resembles a half pipe, and lateral portions that extend radially outward from sides of the middle portion towards the inner diameter of the downhole tubular.
 17. A method of pumpdown operations in a wellbore comprising: providing a downhole tool having a pumpdown valve that is changeable from an open configuration and substantially parallel with an axis of the wellbore, to a closed configuration and substantially perpendicular with the axis of the wellbore; deploying the tool in the wellbore; dropping the tool in the wellbore when the pumpdown valve is in the open configuration; and pumping fluid into the wellbore to urge the tool deeper into the wellbore when the pumpdown valve is in the closed configuration.
 18. The method of claim 17, further comprising pulling the tool upward within the wellbore when the pumpdown valve is in the open configuration. 